Well completion method and system



ug- 2, 1966 c. B. coRLEY, JR

WELL COMPLETION METHOD AND SYSTEM 3 Sheets-Sheet 1 Filed Nov. 20. 1963 FIG., 3.

FSG. l.

ATTORNEY Aug. 2, 1966 c. B. coRLEY, JR

WELL COMPLETION METHOD AND SYSTEM 5 Sheets-Sheet 2 F l Go 5 Filed NOV. 20, 1963 FIG. 4.

INVEN TOR.

CHARLES B. CORLEYJR.

ATTORNEY.

Aug. Z, 1966 c. B. coRLEY, JR

WELL COMPLETION METHOD AND SYSTEM 5 Sheets-Sheet 5 Filed NOV. 20, 1963 FIG. 6.

INVEN TOR.

CHARLES B. CORLEY, JR.

BYQLMM JIM AT TORNEY United States Patent 3,263,753 WELL COMPLETION METHOD AND SYSTEM Charles B. Corley, Jr., New Orleans, La., assigner, by

mesne assignments, to Esso Production Research Company, Houston, Tex., a corporation of Delaware Filed Nov. 20, 1963, Ser. No. 324,979 8 Claims. (Cl. 16d- 189) This invention relates to oil and gas wells. More particularly, this invention is an improved method and system for using three tubing strings for a dual completion subsea-wellhead well rather than Vthe four tubing strings required when: (1) subsurface well tools are used which employ iluid pressure and .circulation for installation and removal `and (2) no fluid pressure is desired on the casing-tubing annulus.l

Briefly described, this new system includes a first tubing string for the production of fluids from an upper producing sub-surface formation and a second tubing string for the production of fluids from `a lower producing subsurface formation. A third tubing string is also included in the system. The three tubing strings are iluidly interconnected. Means are provided for selectively directing the ilow o|f iluid from the upper producing subsurface formation through one of said three tubing strings and directing the ilow of fluid from the lower producing subsurface formation through a second of the three `tubing strings. The means for selectively producing .the fluids is a iluid pressure removable sealing member.

The invention, as Well as its many advantages, may be understood by reference -to the following detailed description and drawings in which:

FIG. l is a schematic, elevational view showing the use of a iluid pressure removable sealing and fluid directing member;

FIG. 2 is a view similar to FIG. 1 showing the use of a different fluid pressure removable sealing and fluid directing member;

FIG. 3 is a View similar to FIG. 1 and FIG. 2 sholwing the use of still another iluid pressure removable sealing and fluid directing member;

FIG. 4 is a schematic, elevational view of another arrangement of the three tubing strings and -showing a particular type of iluid pressure removable sealing and iluid directing member;

FIG. 5 is a view similar to FIG. 4 showing the use of a different type of fluid pressure removable sealing and fluid directing member;

FIG. 6 is a View similar to FIGS. 4 and 5 showing a different method for selectively controlling the flow 0f fluids; and

FIG. 7 is a schematic, elevational view of the three tubing string `arrangements showing the use of frangible pump plugs to prevent excessive loss of returns.

Referring to the drawings and more particularly to FIG. l, an oil and gas producing well is shown including the usual casing 10 cemented to the sides of the well by the usual cement 12. The Well traverses an upper producing zone 14 and a lower producing zone 16. Perforations 18 have been formed through the casing 10 and cement 12 into the producing zone 14. Perforations 20 have been formed through casing 10 and cement 12 into the producing zone i16.

A first tubing string 22 extends to a point adjacent the upper producing subsurface formation 14. A second tubing string 24 extends to a point adjacent the lower producing formation 16. Upper tubing-casing packing means 26 is provided about the tubing strings 2 2 and 24. Lower tubing-casing packing means 28V is provided about the tubing string 24. Thus, it can lbe seen that during normal producing operations, iluids produced ICC from subsurface formation 14 are ilowed upwardly through tubing string 22. Similiarly, .fluids produced from subsurface formation 16 are flowed upwardly through tubing 24.

A third tubing string 30 is also included in 4the new system. Tubing string 30 is connected adjacent the bottom thereof to tubing string 22 by means of fluid bypass 32. Tubing string 30 is also connected `to tubing string 24 by means of fluid bypass 34.

Landing means, such as projections 36, are provided in lluid .bypass 32. A iluid pressure removable sealing and fluid directing member 38 is shown resting upon the landing projections 36. The fluid .pressure removable sealing and fluid directing member 3S shown in FIG. 1 includes an upper piston 40 and a lower piston 42 interconnected by a solid rod 44. The cross-sectional area of piston 4l) is greater `than the cross-sectional area of piston 42. Thus, when desired, the fluid pressure removable sealing and iluid directing member 38 can be removed from tubing string 30 by fluid circulation down either tubing string 22 or tubing string 24 and upwardly in tubing string 30.

The system shown in FIG. 1 may be used for the production of fluids from subsurface formation 14 through tubing string 22 and the production of fluids from subsurface formation 16 through tubing string 24. During producing operations, Aa small amount of pressure may be applied down tubing string 30 and against the top of piston 40. This small pressure assures that the iluid pressure removable sealing and fluid directing member 38 is kept in the desired position on landing projections 36. The member '3S may be provided, if desired, with downwardly extending spring latch fingers.

Under certain circumstances, it may be desirable or even necessary to divert the flow of fluids from either tubing string 22 or tubing string 24 to .the tubing string 30. This may occur, f-or example, if either tubing string 22 or ytubing string 24 becomes plugged or develops a leak.

If `for some reason it becomes necessary or desirable to divert the ilow of fluids from subsurface formation 14 from tubing string 22, the fluid pressure removable sealing and iluid directing member 46 shown in FIG. 2 may be used. The sealing and fluid directing member 46 includes an upper piston 48 and a lower piston 50 interconnected by a hollow rod 52, thus providing a bore `54. The cross-sectional area of piston 48 is greater than the cross-sectional area of piston 50 so that the sealing and fluid directing member 46 can lbe removed from tubing string 30 by -iluid circulation down tubing string 24 and upwardly through tubing string 30. When the sealing and -iluid directing member 46 is properly placed, the fluids produced from subsurface formation I14 flow through fl'luid bypass 32, bore 54 in sealing and fluid directing member 46, and upwardly to the earths surface through tubing string 3f). The fluids from subsurface formation 16 ilow through tubing string 24.

If it is desired to divert the iflow of fluids from sub surface formation |16 from tubing string 24 to tubing string 30, the fluid pressure removable sealing and iluid directing member v56 shown in FIG. 3 4may be used. As shown in \FIG. 3, the sealing and fluid directing member 56 includes an upper piston 58 and a lower piston 64. A port 60 Iis provided in the hollow portion of rod 62 of sealing and fluid directing member 56 to iluidly conneet the bore with fluid bypass 34 and tubing string 24. With the sealing and iluid directing member 56 in place on the landing means 36, the iluids produced from subsurface producing formation 16 ilow through bypass 34, port 60, and bore 65 to tubing string 30. The fluids produced from subsurface formation 14 flow upwardly through tubing string 22.

FIGS. 4 through 6 show an arrangement of three tubing strings which may be used for the alternate production of vfiuids through a common tubing string from either of the two producing intervals. The first tubingv string 66 extends to a point adjacent producing formation 14. The second tubing string 68 extends to a point adjacent producing formation 16. The third tubing string 70 is connected to tubing strings 66 and 68 by bypass lines 72 and 74, respectively.

In the embodiment shown in FIGS. 4 through 6, the tubing string 70 is extende-d through the upper packer 76and the lower packer 78. With placement of the fluid pressure removable sealing and fiuid directing member 80 including upper piston 82 and lower piston 84 interconnected by solid rod 86 upon the landing means 58 (see FIG. 4), the productionof fluids from subsurface formation 14 and subsurface formation 16 is obtained through tubing string 66 and tubing string 68, respectively. Members 89 are outwardly biased by yieldable springs (not shown) and shaped to fit in landing means 88.

'In FIG. 5 there is shown the placement of fluid pressure removable sealing and fiuid directing member 90 across interconnecting lines 72 and 74. The sealing and fluid directing member 90 includes upper piston 92 and lower piston 94 interconnected by hollow rod 96. With the sealing and fluid directing member 90 placed as shown `in FIG. 5, the production of uids from the lower zone 16 may be diverted yfrom tubing string 68 to tubing string 70.

As shown in FIG. 6, the tubing string 70 may also be used for production of fluids from the upper formation 14 utilizing the same fiuid pressure removable sealing and fi'uid directing member as shown -in FIG. 5. This may be accomplished by installing a temporary pumpout plug 98 in the lower end of tubing string 70. Perforations 100 are then formed in tubing string '70 adjacent the producing zone 14 and the sealing member 90 installed as shown in FIG. 6. Downwardly extending spring latch fingers :101 are provided on pump-out plug 98.

yFrom the foregoing, it can be seen that with my new subsea well system, the fluids from two vertically spaced apart formations can be produced through two of three tubing strings, selectively. Also, various other operations can Ibe conducted utilizing this new system. For example, storm chokes may be installed and retrieved; and bottom-hole pressures may be obtained by pumping a pressure instrument to near the well bottom. Also, a

fluid activated pig may be used to remove paraffin from the tubing strings.

If the subsea well has a high loss of returns as indicated by a pressure test, frangible pump plugs may be installed at the lower ends of tubing string 22 and tubing string 24 as shown in FIG. 7. Frangible pump plug |102 is shown positioned on landing means 104 in the buttom of tubing string 22. Frangible pump plug 106 is shown posii-toned on landing means 108 in the bottom of tubing string 24. These frangible pump plugs can be placed on the landing means by fluid circulation in order that the pressure removable sealing and fluid directing members shown in FIGS. l through 6 may be removed to carry out additional operations. The frangible pump plugs 102 and 4106 can be forced out of the lower ends of their respective tubings by application of fiuid pressure to restore the well to production.

I claim:

1. In a subsea well traversing a first producing subsurface formation and a second producing subsurface for-mation vertically separated from said first producing subsurface forma-tion: a first tubing string extending to a point adjacent the upper producing subsurface formation; a second tubing string extending to a point adjacent the lower producing subsurface formation; upper packing means about the first tubing string and the second tubing string and above the upper producing subsurface formation; lower packing means about the second tubing string and between the upper and lower producing subsurface formations; a third tubing string; a first conduit interconnecting the first tubing string and the third tubing string; a second conduit interconnecting the second tubing string and the third tubing string; and Ameans for directing the flow of fluid .from the upper producing subsurface formation through one of said three tubing strings and directing the iiow of fiuid from the lower producing subsurface formation through a second of said three tubing str-ings, said means including a fluid pressure removable sealing and uid directing member.

2. In a subsea well traversing a first producing subsurface formation and a second producing subsurface formation vertically separated from said first producing subsurface formation: a first tubing string extending to a point adjacent the upper producing subsurface formation; a sec-ond tubing string extending to a point adjacent the lower producing subsurface formation; upper pack` ing means about the first tubing string and the second tubing string and above the upper producing subsurface formation; lower packing means about thesecond 'tubing string and between the upper and lower producing subsurface formations; a third tubing string; a first conduit interconnecting the first tubing string and the third tubing string; a second conduit interconnecting the second tubing string and the third tubing string; landing means provided in the third tubing string; and a fiuid pressure removable sealing and fluid directing member adapted to rest on the landing means and direct the flow of fluids from the upper producing subsurface formation and the lower producing subsurface formation through the first tubing string and the second tubing string, respectively.

3. In a subsea well traversing a first producing subsurface formation and a second producing subsurface formation vertically separated from said first producing subsurl face formation: a rst tubing string extending to a point adjacent 'the upper producing subsurface formation; a second tubing string extending to a point adjacent the lower producing subsurface formation; upper packing means about the first tubing string and the secon-d tubing string and above the upper producing subsurface formation; lower packing means about the second tubing string and between the upper and lower producing subsurface formations; a third tubing string; a first conduit interconnecting the first tubing string and the `third tubing string; a second conduit interconnecting the second tubing string and the third tubing string; landing means provided in the third tubing string; and a fiuid pressure removable sealing and fluid directing member adapted to rest on the landing f means and direct the flow of fiuids from the upper producing subsurface formation and the lower producing subsurface formation through the third tubing string and the second tubing string, respectively.

4. `In -a subsea well traversing a first producing subsurface formation and a second producing subsurface formation vertically separated from said first producing subsurface formation: a first tubing string extending to a point adjacent the supper producing `sub surface formation; a second tubing string extending to a point adjacent the lower producing subsurface formation; upper packing means about the first tubing string and the second tubing string and above the upper producing subsurface formation; lower packing means about the second tubing string and between the upper and lower producing subsurface formations; a third tubing string; a -first conduit interconnecting the `first tubing string and the third tubing string; a second conduit interconnecting the second tubing string and the third tubing string; landing means provided in the third tubing string; and a fiuid pressure removable sealing and fluid directing member adapted t-o rest on the landing means and direct the flow of fluids from the upper producing subsurface formation and the lower producing subsurface formation through the first tubing string and the third tubing string, respectively.

5. In a subsea well traversing a first producing subsurface formation and a second producing subsurface formation vertically separated from said first producing subsurface formation; a first tubing string extending to a point adjacent the upper producing subsurface formation; `a second tubing string extending to a point adjacent the lower producing subsurface formation; a third tubing string extending to a point adjacent the lower producing subsurface formation; upper packing means about said three tubing strings and above the upper producing subsurface formation; lower packing means about said second and third tubing strings and between the upper and lower producing subsurface formations; a rst conduit interconnecting the first tubing string and the third tubing string; a second conduit interconnecting the second tubing string and the third tubing string; landing means provided in the third tubing string; and a Iiiuid :pressure removable sealing and uid directing member `adapted to rest on the landing means and direct the flow of `fluid from the upper producing subsurface formation through one of said three tubing strings and the flow of iuid from the lower producing subsurface formation through another of said three tubing strings.

6. A system in accordance with claim 5 wherein the fluid pressure removable sealing and fluid directing member is adapted to direct the flow of uids from the upper and lower producing subsurface formations through the first and second tubing strings, respectively.

7. A system in accordance with claim 5 wherein the fluid pressure removable sealing and fluid directing member is adapted to direct the ow of iluids from the upper and lower producing subsurface formations through the first and third tubing strings, respectively.

8. A `system in accordance with claim 5 wherein the third tubingstring has perforations formed therein at a point adjacent the upper producing subsurface formation, a plug lis provided in the third tubing string below the perforations, and the uid pressure removable sealing and fluid directing member is ladapted to direct the iiow of fluids from the upper and lower producing subsurface formations through the third and second tubing strings, respectively.

References Cited by the Examiner UNITED STATES PATENTS 2,923,357 2/1960 Dafiin 166-46 3,032,113 4/1962 Dollison 166-189 3,040,813 6/ 1962 Tausch et al. 166-46 CHARLES E. OCONNELL, Primary Examiner.

J. A. LEPPINK, Assistant Examiner. 

1. IN A SUBSEA WELL TRAVERSING A FIRST PRODUCING SUBSURFACE FORMATION AND A SECOND PRODUCING SUBSURFACE FORMATION VERTICALLY SEPARATED FROM SAID FIRST PRODUCING SUBSURFACE FORMATION: A FIRST TUBING STRING EXTENDING TO A POINT ADJACENT THE UPPER PRODUCING SUBSURFACE FORMATION; A SECOND TUBING STRING EXTENDING TO A POINT ADJACENT THE LOWER PRODUCING SUBSURFACE FORMATION; UPPER PACKING MEANS ABOUT THE FIRST TUBING STRING AND THE SECOND TUBING STRING AND ABOVE THE UPPER PRODUCING SUBSURFACE FORMATION; LOWER PACKING MEANS ABOUT THE SECOND TUBING STRING AND BETWEEN THE UPPER AND LOWER PRODUCING SUBSURFACE FORMATIONS; A THIRD TUBING STRING; A FIRST CONDUIT INTERCONNECTING THE FIRST TUBING STRING AND THE THIRD TUBING STRING; A SECOND CONDUIT INTERCONNECTING THE SECOND TUBING STRING AND THE THIRD TUBING STRING; AND MEANS FOR DIRECTING THE FLOW OF FLUID FROM THE UPPER PRODUCING SUBSURFACE FORMATION THROUGH ONE OF SAID THREE TUBING STRINGS AND DIRECTING THE FLOW OF FLUID FROM THE LOWER PRODUCING SUBSURFACE FORMATION THROUGH A SECOND OF SAID THREE TUBING STRINGS, AND MEANS INCLUDING A FLUID PRESSURE REMOVABLE SEALING AND FLUID DIRECTING MEMBER. 